Removable subsurface well tool



April 7, 1953 Filed Sept. 15, 1948 R. c. QAK'ER ETAL 4 Sheets-Sheet 3INVENTORS.

REUBEN C BAKE Hl/LL/P B. ZIMMEEMAIV,

Patented Apr. 7, 1 953 REMOVABLE SUBSURFACE WELL TOOL Reuben C. Baker,Coalinga, and Phillip B. Zimmerman, Los Angeles, Calif., assignors toBaker Oil Tools, 1110., Vernon, Calif., a corporation of CaliforniaApplication September 13, 1948, Serial No. 49,004

22 Claims.

The present invention relates to sub-surface well tools, and moreparticularly to tools useful in the performance of cementing, acidizing,washing, testing, anchoring, production and other operations in wellbores.

The operation of certain types of well tools is effected by moving theirparts relatively to each other through manipulation of tubular stringsto which the tools are attachable. The relative movement may beobtainable by resisting or preventing movement of one or more of thetool parts through the use of instrumentalities engaging the wall of thewell conduit or formation. Although resistance to movement is requiredduring the performance of some of the operations in the well bore, suchresistance is not always desirable. As an example, removal of a welltool from a casing is expedited if the tubing or drill pipe joints areunscrewed by holding the section above the rotary table stationary androtating the remainder of the tubular string in the hole. This rotationalso revolves the casing engaging instrumentalities, sliding or draggingthem around and along the casing wall, with potential damage to theinstrumentalities and to other parts of the well tool.

Accordingly, an object of the present invention is to avoid damage tothe casing or formation engaging instrumentalities of a well tool duringrotation of the tubular string to which the tool is attached.

Another object of the invention is to provide a sub-surface well toolhaving casing or formation engaging elements that are not dragged aroundor along the casing or formation wall during movement of the tooltherein. More specifically, dragging of such elements is avoided duringrotation of the tubular string to which the tool is attached.

A further. objectof the invention is to provide 7 a tool embodying adrag device for controlling operation of the tool, in which the dragdevice need not be dragged frictionally around the casing wall duringrotation of the tubular string to which the tool is attached.

Another object of the invention is to uncouple a drag device or the likefrom the well tool, of which it forms a part, in order that rotation ofthe drag device need not occur during rotation of the tubular stringattached to the tool.

Still a further object of the invention is to disengage a drag device,or the like, from the wall of. a well casing, to prevent frictionalengagement of the device with such casing wall during rotation of thedrag device. 7 l

Yet another object of the invention is to insure the pulling of a dragdevice, forming part of a well tool, through a well conduit or formationregardless of the direction of longitudinal movement of the device.

Certain tools embody elements that are normally in retracted positionand which are expandible outwardly against a well casing or similarconduit. As an example, slips may be expanded into anchoring engagementwith a casing to prevent upward movement of a well tool, of which theslips form a part. Thereafter, the slips may be retracted to enablewithdrawal of the tool from the well casing. Care must be exercisedagainst inadvertent expansion of such slips during elevation of thetool, since it might result in serious damage to the tool, the runninginstring attached to the tool, and'other well equipment.

Another object of the invention is to insure against inadvertentexpansion of the slips after they have been retracted from their outwardposition.

A further object of the invention is to lock the slips in retractedposition to preclude their outward expansion.

This invention possesses many other advantages, and has other objectswhich may be made more clearly apparent from a consideration of several.forms in which it may be embodied.

, Such forms are shown in the drawings accompanying and forming part ofthe present specification. These forms will now be described in detail,illustrating the general principles of the invention;' but it is to beunderstood that such detailed description is not to be taken in alimiting sense, since the scope of the invention is best defined by theappended claims.

Referring to the drawings:

Figure 1 is a longitudinal view, partly in elevation and partly insection, of a well tool embodying the invention disposed within a wellcasing, with its parts in retracted position;

Fig. 2 is an enlarged sectional view of the drag and lock portion of thetool shown in Fig. 1, with the drag device uncoupled from the remainderof the tool;

Fig. 3 is a view similar to Fig. l of the Well tool anchored inpacked-off condition within the well casing;

Fig. 4 is a cross-section taken along the line 4-6on Fig. 1;

Fig. 5 is a cross-section taken along the line 5-5 on Fig. 1;

Fig. 6 is a cross-section takenalong the line Fig. 7 is a longitudinalsection through an- 3 other form of drag and lock device, forming theupper portion of the well tool disclosed in Fig. 1;

Fig. 8 is a partly sectional and partly elevational view of the deviceshown in Fig. 7 with its outwardly bowed leaf springs disengaged fromthe wall of the well casing;

Fig. 9 is a longitudinal section through still another embodiment of adrag and lock device, forming the upper portion of the tool shown inFig. 1;

Fig. 10 is a longitudinal View, partly in section and partly inelevation, of the drag device disclosed in Fig. 9 shifted fromengagement with the casing wall;

Fig. 11 is a cross-section taken along the line IIII on Fig. 9; and

Fig. 12 is a cross-section taken along the line I2-I2 on Fig. 9.

The invention is exemplified in the drawings as applied to a well packerA of the retrievable type. It is to be understood, however, that theinvention is also applicable to other well tools, and for controllingelements other than slips and packings hereinafter referred to.

The packer A is adapted to be run in a well bore or casing B on the endof a tubular runningin' string'C threadedly, or otherwise, attached tothe upper end of the tubular mandrel or body portion ill of the packer.The lower end of this mandrel or body portion ID is threaded into theupper end of a lower tubular packer body II, to which is attached apacking actuator I2 in the form of a guide.

A tapered expander I3 is mounted on the body part II. It is preferablyprevented from turning with respect to the latter by a key I4 secured tothe exterior of the body and received within a keyway I5 in theexpander; so as to permit relative longitudinal movement between thebody I I and expander I3 while preventing rotation therebetween. Whenthe tubular string C and body It, Ii are elevated, the packing actuatorI2 is moved toward the expander I3 to compress an intervening packingsleeve I6, surrounding the body, and force it outwardly into engagementwith the wall of the casing B. Such actuation of the packing sleeve I6only occurs when the tapered expander I3 is prevented from movingupwardly, which results from shifting of the expander within a pluralityof slips I1, and outward expansion of the latter against the wall of thecasing.

The slips IT have tapered inner surfaces I8 cooperating with companiontapered surfaces I9 on the expander, the inclination of such surfacesbeing such as to move the slips I'I outwardly toward the casing when theexpander I3 is elevated. Conversely lowering of the expander I3 withrespect to the slips I'I permits the latter to release from the casingwall and move inwardly to retracted position.

It is, accordingly, apparent that elevation 01 the tubular string C andpacker body II), II can elfect anchoring of the tool, through engagementof the slips I l with the casing B under the influence of the taperedexpander [3. Such elevation can also efiect compression orforeshortening of the rubber packing sleeve I6 between the expander I3and guide I2, to produce its radial outward expansion into sealingengagement with the casing wall.

The slips I? are held together for joint movement along the taperedexpander I3 to and from engagement with the casing 13 by pin-connectingthem to the lower ends of link 20, whose upper ends extend between thefingers 2I of a slip ring spasm 22. This ring is also provided with aperipheral groove 23 into which pins 24, projecting in both directionsfrom the sides of the links 20, may extend, in order to couple all ofthe links 29 and slips I! for movement jointly with the slip ring 22.Outward movement of the upper ends of the links 20 is prevented by astop ring 25 suitably secured to the slip ring 22.

The slip ring is connected to a drag and lock device 26 by a swivelmechanism 21, in order to permit rotation of the slips IT and slip ring22 without correspondingl rotating the drag device 26. The main purposeof the drag device 26 is to resist longitudinal movement of the slips I1within the well casing B.

The drag device 26 includes an outer ratchet member 28, consisting of alower ring 29 threaded into an upper ratchet sleeve 32. The ratchet ring29 and slip ring 22 are adjacent one another, and are provided withoutwardly directed flanges 3|, 32 receivable within an internalcircumferential groove 33 in a tie ring 34 having upper and lowerinwardly directed flanges 35, 36 disposed above and below the ratchetring and tie ring flanges SI, 32, respectively. For convenience ofassembly, the tie ring 34 may be made in two halves that are movedradially inwardly to dispose the flanges 35, 36 above and below theratchet ring and slip ring flanges SI, 32. This two-piece tie ring isprevented from coming apart by an encompassing circumferentiallycontinuous sleeve 31, which is prevented from dropping ofi the ring byone or more screws 38 threaded into the ring and disposed within holes39 in the sleeve. It is apparent that the tie ring 34 and the flangesSI, 32 on the ratchet ring 29 and slip ring 22 form a swivel connection21 between the drag device 26 and the slips I1.

The drag and lock device 26 comprises the outer ratchet member 30, 29,which may slide relatively along the mandrel H3, or be coupled thereto.The sleeve 30 of this member is coupled to the lower end of the dragdevice 26, which includes a plurality of circumferentially spacedoutwardly bowed leaf springs :38, extending upwardly along the mandrel I0, and frictionally engaging the casing B.

The frictional engagement of the springs 20 with the casing B tends toresist longitudinal movement of the slips I! through the well casing.Upon reaching the desired setting point in the casing, if the tubularmandrel If) is permitted to move upwardly with respect to the dragdevice 26, such elevation would also elevate the lower packer body II,and, through the guide I2 and packing sleeve I6, elevate the expander I3within the slips I7, since the latter are prevented from moving upwardlyby the drag device. Such elevation of the expander I3 forces the slipsI'i radially outward into anchoring engagement with the casing wall.With the slips i7 anchored to the casing B, the expander I3 is preventedfrom moving upwardly. Accordingly, a continuation of the upward movementof the tubular string C and body 10, I I moves the guide ring I2 towardthe expander I 3, in order to foreshorten the packing sleeve I6 andshift it into firm sealing engagementwith the casing B and the packerbody IE.

Lowering of the tubular string C and packer body II II with respect tothe drag device 26 permits retraction of the packing sleeve I6 from thecasing, and produces corresponding downward movement of the taperedexpander I3, by virtue of engagement of the body shoulder 46 with anexpander flange 47, so that the slips H are moved inwardly to retractedposition. Such inward retraction will occur, since downward move ment ofthe slips is prevented by the friction spring drag device 26.

It is to be noted that upward movement of the tubular body can effectanchoring of the packer A in packed-off condition within the well casingB,- and that lowering of these members can effect release of the packer.In order to allow the tubular body H], H to be elevated withoutanchoring the tool in the well casing, some means is provided forpreventing the relative longitudinal movement between the slips I? andtapered expander I3 upon elevation of the tubular body. In the presentinstance, such means is afforded by a ratchet or one-way clutch type oflock de vice disposed between the upper body or mandrel l and theratchet sleeve 39.

The ratchet sleeve 30 has an inner surface 56 tapering upwardly andinwardly, that cooperates with a correspondingly tapered surface ti on asegmented ring 52, to urge the ring inwardly, in order that the internalteeth 53 of the ring are disposed for clutching engagement with.external ratchet teeth 54 formed on the periphery of the upper tubularbody or mandrel iii. The se mented ring 52 includes a plurality ofadjacent segments 55 (see Fig. disposed a substantial distance aroundthe periphery of the mandrel Iii, such segments being urged inwardly bya split, contractile spring or snap ring disposed within a peripheralgroove El in the segments. This ring 56 tends to urge the segments 55inwardly, to effect engagement of their ratchet teeth 53 with thecompanion teeth 5& on the mandrel. Such ratchet teeth may be constitutedby an upwardly facing ratchet or buttress type of thread 515 on themandrel is, engaging with a companion downwardly directed ratchet thread5t formed jointly within the segments 55. a

' A stop 58, in the form of a key, is secured to the ratchet sleeve 38,and engages one end of the segmented ring 52, to prevent rotation of thesegmented ring relative to the ratchet sleeve. The other end of the ring52 has an inwardly directed key or projection 59 disposed within alongitudinal keyway Gil in the mandrel It].

Because of the ratchet or one-Way clutch type of lock device described,the mandrel is can be moved downwardly without interference by the lockdevice, since the mandrel ratchet teeth 55 will merely ratchet freelyover the companion teeth its on the segments 55. However, upwardmovement of the mandrel it will cause its teeth 54 to engage the segmentteeth 53 and move the segments 55 upwardly with it, shifting themslightly toward the narrow portion of the tapered surface 56 in theratchet sleeve 3t, and wedging the segments firmly between the mandreliii and ratchet sleeve 30, which effectively couples the mandrel it anddrag device 25 together against relative upward movement. In otherwords, the

since the "other -end of the segmented ring is pr" vented from moving bythe stop 58 secured to the ratchet sleeve 39. When the mandrel is thusturned to free the segments 55 from its teeth 5d, the mandrel I0 may bemoved upwardly within the segments 55 and the ratchet sleeve to, inorder to shift the expander 13 upwardly within the slips l1 and urge thelatter into anchoring engagement with the casing B. As above indicated,a continuation of this upward movement foreshortens the packing sleeveis and expands it outwardly against the casing.

When the slips I1 and packing 16 are to be retracted, it is merelynecessary to lower the tubular string C and mandrel I0, which will lowerthe abutment 12 away from the expander l3, allowing the packing sleeve[6 to retract and also cause the body shoulder 46 to engage the expandershoulder 41, shifting the expander downward-' 1y relative to the slips Hand effecting retraction of the latter. Such downward movement can occurwithout regard to the imposing of turning effort on the tubular string 0and packer body l0, H because of the one-way ratchet arrangement betweenthe mandrel threads 54, and segmented ring threads 53.

With the segmented ring 52 released by reverse turning of the tubularstring C and packer body Ill, I! upward movement of these latter memberswill again automatically couple the mandrel ill to the ratchet sleeve 30and drag device 26, in order that upward movement of the tubular stringC and packer body [0, II will be ineffective to anchor the packer to thewell casing. The well tool, therefore, can be removed to the top of thewell bore.

As described above, the outwardly bowed leaf springs 40 engage thecasing B to resist longitutwo'parts It, 26 are locked together forupward movement as a unit. Accordingly, the slips ll are also looked tothe mandrel It and will move upwardly with it.

When it is desired to shift the mandrel it) upwardly within the dragdevice 26, and with respect to the slips ill, in order to anchor theslips to the casing B, the tubular string C and upper ,body or mandrelll! connected thereto are rotated a partial revolution, preferably tothe right. Such rotation causes the mandrel ill to act upon the segmentkey 59 and expand the segments 55 outwardly to the extent in which theirteeth 53 are completely out of engagement with the mandrel teeth 54.Such expansion will occur,

dinal movement of the slips. ll therewithin. These springs also resistrotation of the ratchet sleeve 36 and enable rotation of the tubingstring C and mandrel ill to effect unclutching of the segmented ring 52from the mandrel teeth 54.

After the operation has been performed in the well bore, it is desiredto remove the tool from the well casing. Such removal can be expeditedbydisconnecting the tubing string joints at the rotary table (notshown), through holding the stand of tubing abovethe table stationary,and through rotating the rotary table to rotate the tubing string C andthe well tool A attached thereto. Such rotation ordinarily occurs to theright. If the drag device 26 shown in Figs. 1, 2, 3 were coupleddirectly to the ratchet sleeve 30, rotation of the tubing string C andmandrel It would revolve the drag springs All around the easing B, andmight severely damage them. In the form of the invention disclosed inFigs. 1 to 6, inclusive, rprovision is made for uncoupling the dragdevice 26 from the remainder of the tool, in order that it need notrotate with the remainder of the tool. In achieving the objective justmentioned, the lower ends of the springs 40 are connected-to a lowerdrag collar 10 by an encompassing ring H and screws 12. The upperends'of the springs are similarly connected to an upper drag collar 10a,slidable on the mandrel ill, by an encompassing ring Ha and screws 12a.This lower drag collar has internal threads 13 adapted to engage andcooperate with external threads 14 formed on the upper portion of acoupling or drag sleeve 75 threadedly, or otherwise, secured to theratchet sleeve 30. The threaded connection 13,

His preferably left hand; Inadvertent separa-" tion between the dragsleeve 75 and. ratchet sleeve 30 is prevented by a suitable look screw16 threaded into the ratchet sleeve and bearing against the drag sleeve.

Originally, the lower drag collar occupies a position at the upper endof the drag sleeve 15, the extent of the upward threading of the collarbeing determined by engagement of its lug or projection 11 with anoutwardly directed lug or projection 18 on the drag sleeve. Rotation ofthe drag sleeve 15 to the right will efiect downward feeding of thelower drag collar 10 along the sleeve I5, before the sleeve projection18 can engage the collar projection 11, so as not to interfere withdownward movement of the lower collar 10* along the sleeve. Theprojections 11, 18 will be engaged upon upward screwing of the lowercollar 10 on the sleeve 75, to limit the extent of such upward movementand to prevent jamming of the threads 13, 14.

In order to prevent rotation of the ratchet sleeve 30 and drag sleeve 15during manipulation of the segmented lock ring 52, a frictionalrestraint is imposed between the lower drag collar H1 and the dragsleeve 15. In the form disclosed in Figs. 1 to 6, inclusive, suchfrictional restraint is obtained by causing a plurality ofcircumferentially spaced brake shoes 19 to bear frictionally against theouter ends of the external threads 74. These brake shoes have stem 80extending through bores 8| in a ring portion 82 depending from the lowercollar ring 1|. The stem 8|] of each brake shoe is slidable through aspring seat 83 threaded within the bore 8|. A helical spring 84 isdisposed in each bore, bearing against The springs 84 provide enoughfrictional force of the shoes 19 against the sleeve threads 14 as toresist rotation of the ratchet sleeve to an extent sufiicient to insureexpansion of the segmented ring 52 to its unclutched position, uponrotation of the tubing string C and mandrel |ll to the right, asdescribed above. The brake shoes 19, however, do not exert sufiicientfrictional force to transmit rotary motion of the coupling or dragsleeve 15 to the drag springs and revolve the latter around the casing.Instead, the brake shoes 19 will slip before that occurs.

A rubber wiper ring 85 may be secured in the upper end of the dragsleeve 15 to prevent foreign substances from moving downwardly throughthe clearance space between the drag sleeve 15 and mandrel l0, and.possibly clog the ratchet clutch mechanism -44.

the pulling of the drag device 26 through the well casing B,irrespective of its upward or downward movement through the well casing.This stop device is adjustable and includes a two-part stop ring 81disposed within a circumierential groove 88 in the mandrel (see Figs.

1, 2, 3, 6). The two halves of this stop ring are separated by keys 89welded or otherwise secured to the mandrel ID. The stop ring hasexternal drag sleeve 15 do not extend throughout its length,v butterminate a substantial distance 55, A stop device 86 is also providedfor insuring above the upper end of the ratchet sleeve 30. Theunthreaded portion 15a of the sleeve has a diameter no greater than theroot diameter of the threads 74, in order to permit the lower collar H!to be disposed therealong. The unthreaded portion 75a of the sleeve issufiicient in length to permit complete unscrewing of the lower dragcollar I!) from the threaded portion 14, and also to accommodate thebrake shoes 19.

The well tool A is run in the well casing with the parts disposed in theposition shown in Fig. 1, except that the segmented ring 52 may be inits inward or clutching position. The stop sleeve 9| is adjusted byrotating it on the threaded stop ring 81 until its lower end engages theupper end of the drag sleeve l5. It is maintained in this adjustedposition by a suitable screw 92 threaded through the sleeve BI andbearing against the mandrel m. The lower drag collar 19 is at the upperend of the drag sleeve 15, and the upper drag collar 10a is disposed asubstantial distance above the stop sleeve 9|.

When the position in the well bore has been reached at which the tool isto be anchored in packed-off condition, the tubing string C and mandrelID are rotated to the right to unclutch the ratchet ring 52 from themandrel, which per= mits the tubing string C and mandrel ID to beelevated and efiect engagement of the slips l1 and the packing It withthe wall of the well casing. Upward movement of the mandrel within thedrag device 26 is permitted, because of the space that has been allowedbetween the upper end of the stop sleeve 15 and the upper drag collar a(see Figs. 1 and 3). Moreover, rotation of the ratchet sleeve 36 duringturning of the mandrel H3 is prevented by the frictional engagement ofthe brake shoes 59 upon the threads 14 of the drag sleeve 75, which isconnected to the ratchet sleeve 3%.

When the well tool A is to be removed from the well casing, the tubingstring C and mandrel 1c are lowered to retract the slips H and thepacking It to their initial positions shown in Fig. 1. The tubing stringC is then rotated to rotate the mandrel Ill. Such rotation will expandthe ratchet ring 52, and, through the ratchet ring 52 and stop key 58,will rotate the ratchet sleeve 30 and the drag sleeve 15. Since thethreaded interengagement 13, 74 between the drag sleeve 75 and lowerdrag collar H3 is left hand, and since the drag springs to engage thecasing B to resist rotation of the lower drag collar, the rotation ofthe drag sleeve 15 to the right will thread the lower drag collar Illdownwardly along the sleeve 35, until the lower drag collar iscompletely unscrewed from the threaded portion of the drag sleeve. Thefriction force exerted by the brake shoes #9 against the drag sleevethreads M is only sufiicient to insure unclutching of the ratchet ring52, but it is far less than the frictional force exerted by the dragsprings 40 against the casing wall. As a result, the brake shoes 19 areincapable of preventing rotation of the drag sleeve 75 within the dragcollar 10.

When the lower drag collar has been unscrewed from the threaded portionof the lower drag sleeve, as shown in Fig. 2, the upper drag collar 160.has been lowered to a location adjacent the upper end of the stop sleeve9|.

It is evident that the lower drag collar 10 has been completelyuncoupled from the drag sleeve '35, and that rotation of the drag sleeve75 can occur freely within the lower drag collar "Ill and the springs 48without tending to rotate the latter. The tubing string C and mandrel Imay now be rotated to the extent desired in elevating the tool withinthe well bore for the purpose of uncoupling the sections above therotary table, without fear of revolving the drag springs 49 frictionallyalong and around the walls of the well casing B.

In addition to its function of permitting rotation of the mandrel II]without rotating the drag device 26, after having been unscrewed fromthe drag sleeve I5, the drag and lock device disclosed performs afurther important function. It is to be noted that the unscrewing of thelower drag collar Ill from the drag sleeve I has located the upper dragcollar Eda adjacent the stop sleeve 9 I. It is also to be noted that thelower end of the stop sleeve 9! is adjacent the upper end of the dragsleeve 15, this latter position having occurred upon lowering of themandrel II) to eifect retraction of the slips II and packing I6 from thewell casing. Accordingly, regardless of the coupling or uncouplingposition of the ratchet ring-52, it is impossible to reset the slips I1and packing I6 against the casing B, since the mandrel I0 cannot bemoved upwardly substantially with respect to the slips I'II. This actionis prevented,- because such upward movement is transmitted through thestop ring 87 and stop sleeve 9| tothe upper drag collar Illa, throughthe drag springs Gil to the lower drag collar I9, and from the lowerdrag collar to the drag sleeve 15, because of the engagement of theuppermost thread E3 on the lower collar III with the lowermost thread 14on the threaded portion of the drag sleeve I5. Since the drag sleeve I5is coupled to the slips il through the ratchet sleeve 39, swivel 21 andlinkage 20, it is apparent that upward movement of the mandrel IE3 willalso move the slips 'II upwardly with it, despite the unclutchedposition that the ratchet ring 52 might assume. The tool can be movedout of the hole as rapidly as possible without fear of inadvertentlysetting the slips H, which might cause the tubing string on the tool tobe pulled apart.

The stop sleeve SI and drag device 26 arrangement accomplishes yet afurther function. During lowering of the tool in the well casing, thelower end of the stop sleeve 9! engages the drag sleeve 15, and, throughthe threaded interconnection "I4, I3, moves the lower drag collar I0downwardly in order to pull the drag springs II) through the casing.Similarly, during upward movement of the mandrel II] in removing thetool from the well casing, the stop sleeve 9| engages the upper collarlilo. and again exerts a pulling action on the drag springs 49. Thispulling action insures against buckling of the springs 46, that mightaccompany a pushing action, and avoids damage to or breakage of the leafsprings. The same general functions are performable with the form ofinvention disclosed in Figs. 7

and 8. In this embodiment, the lower ends of 19 key or pin 91, mountedon the collar 10!), andextending into a keyway or groove 98 in the lowerhousing portion 95.

The lower portion of the housing is slidably mounted on the mandrel I0.An enlarged upper housing portion 99 is spaced from the mandrel, beinginteriorly threaded for cooperation with a companion externally threadedhead I96 on the lower end of an outer clutch member I El threadedlyattached to a sub I02 secured to the lower end of the tubular string 0.The threaded connection between the portion 99 and head IIlIl ispreferably right hand. An inner tubular clutch member I93 is mountedwithin the outer clutch member I9l and is threadedly attached to theupper end of the mandrel I9. Leakage between the clutch members IIlI,I63 is prevented by providing one or more seal rings Hi l in suitablegrooves I95 in the inner member I93, which bear against the inner wallof the outer clutch member IIJI.

The inner clutch member I93 has a tapered friction clutch face I96converging in a downward direction and engaging a companion internalclutch face It! in the outer clutch member IIlI. These clutch faces areurged into frictional engagement with one another by a compressedhelical spring I08 bearing against the lower end of the sub I92 andagainst the upper end of the inner clutch member I93.

The well tool disclosed in Figs. 7 and 8 forms the upper portion of thewell tool illustrated in Fig. 1. The only change resides in thesubstitution of one form of drag device 26 for the other. The well toolis run in the well bore with the slips I1 in retracted position, andwith the threaded head I00 of the outer clutch member IOI disposedwithin the upper end of the upper portion 99 of the housing 96. Theupper drag collar 19b is located at the upper end of the keyway 98 (Fig.7, dotted line position), which places a stop ring I09, secured to thelower end of the housing by screws III] or the like, a substantialdistance below the upper drag collar 191). When the tool has reached thesetting point in the well casing, the tubing string 0 is rotated to theright, this rotational effort being transmitted through the coengagingclutch faces I06, I91 to the inner clutch member I03 and to the mandrelIII, which allows the ratchet ring 52 to be expanded and the tubularstring C and mandrel I 0 elevated in effecting setting of the slips I1and packing I6 against the casing B. It is apparent that the stop ringI89 on the lower end of the housing 96 can move with the housingupwardly toward the upper drag collar 101), because of the initial spaceallowed therebetween.

After the operation in the well bore has been performed, the tubingstring C and mandrel II! are lowered to locate the slips I1 and packingIS in their initial retracted positions. Thereafter, the tubing string Cis rotated to the right, which effects upward threading of the housing95 along the outer clutch member I9I, since this housing is preventedfrom rotating by the frictional engagement of the springs Ml against thecasing B, and by virtue of the splined key connection 91, 98. As thehousing moves upwardly, its stop ring I99 eventually engages the upperdrag collar 1%, continued rotation of the tubing string causing thehousing 96 to shift upwardly to a further extent, moving the upper dragcollar 1th with it away from the ratchet sleeve 39 and elongating thesprings 40, to retract them inwardly '11 until they no longer engage thecasing friction ally (see Fig. 8).

The tool may now be elevatedrapidly from the hole, the tubing string Cbeing rotated, if desired, without dragging the springs 40 frictionallyaround the wall of the casing, since the latter have been pulledinwardly of the casing. In addition, the slips ll and packing l6 cannotbe set inadvertently, regardless of the condition of the ratchet clutchring 52, since the upward movement of the tubing string is transmittedto the mandrel Ill and also directly to the slips I! through the clutchmember HH, housing 96, drag device 26, ratchet sleeve 30, swivel 27 andlinkage 20.

The friction clutch Nil, I03 is engaged by just suflicient force totransmit the rotary efiort of the tubular string C to the mandrel In, inorder to expand the ratchet ring 52 out of clutching engagement with themandrel 19. This force, however, is insufficient to transmit the rotaryeffort imparted to the mandrel l0 tothe ratchet sleeve 30 and the dragsprings 40. That is to say, the drag springs engage the casing B withsubstantially greater force than the force of enagement between theclutch faces I96, I61, in order that the clutch will slip before themotion of the tubing string C can rotate the drag springs 40 around andalong the wall of the well casing B during upward feeding of the housing96.

When the drag springs 40 are to be retracted, the tubing string C isrotated to the right, as described above, in order to feed the housing96 upwardly and move the upper drag collar 5% away from the lowerratchet sleeve 39. Such rotation cannot rotate the mandrel l0 and thedrag springs All, in view of the ability of the friction clutch I518,I03 to slip. Accordingly, the outer clutch member It! can be rotated bythe tubular string C with respect to the retracting sleeve or housing96, which is held from rotation by engagement of the drag springs aswith the casing wall, until the latter are distended to the point oflosing contact with the casing wall.

The form of invention disclosed in Figs. 9 to 12,

inclusive, is similar to the embodiment shown in Figs. 1 to 6,inclusive. It forms the upper portion of the tool shown in Fig. 1.

In Figs. 9 to 12, inclusive, the ratchet sleeve 30 is threadedlyconnected to the lower end of the coupling or drag sleeve 15b,disconnection between these two being prevented by a screw 16.

The upper drag collar Illa of the drag device 26 is freely slidablealong the tubular mandrel H], which is connected to the tubing string 0.This collar 10a has the upper ends of the drag springs 40 attached to itin the same manner as the Figs. 1 to 6 embodiment. The lower ends of thedrag springs 49 are secured to a lower drag collar 10d by anencompassing ring Nd and screws 1211, the lower drag collar 10d beingthreadedly connected to the coupling or drag sleeve d.

In order to offer resistance to rotation of the drag sleeve 15b andratchet sleeve 30 during expanding movement of the ratchet ring 52, uponrotation or turning of the mandrel it, one or more spring pressed brakeshoes 19a are disposed in transverse holes 8la in the lower drag collar70d. The shoes are urged into frictional engagement with the exterior ofthe drag sleeve threads 14?) by helical springs 84?) bearing upon theshoes 1% and upon the encompassing ring Md. The brake shoes exertsufiicient frictional force to insure expansion of the ratchet couplingring 52 12 to uncoupling position, but such shoes will slip before therotary effort of the mandrel H] can be transmitted to the drag springs48 with suffieient force to slide them around the wall of the casing B,

A stop device a is secured to the mandrel Ill between the upper andlower drag collars Illa, 10d. This stop device consists of a two partring 8711 received within a groove 83a in the mandrel l0, and held inplace by an encompassing stop sleeve 9|a attached to one ring member bya set screw 92a.

The tool disclosed in Figs. 9 to 12, inclusive, is run in the well borewith the upper drag collar 10a disposed a substantial distance above thestop sleeve 9la, and with the lower drag collar 10d threadedly engagingthe upper end of the drag sleeve 75b. The tool is set in packed-offcondition in the well casing at the desired location in the same manneras in the other forms of the device, upward pulling of the mandrel IE)to efiect the setting being permitted because of the initial spacing ofthe stop sleeve 91a below the upper drag collar 10a.

When it is desired to withdraw the tool from the well casing, themandrel I0 is lowered to retract the slips l! and packing l5, whereuponthe mandrel l0 may be rotated, the rotary force being transmittedthrough the key 59 and coupling ring 52 to the stop member 58 secured tothe ratchet sleeve 30, and from the ratchet sleeve to the coupling ordrag sleeve 26. Since the friction force exerted by the brake shoes 19ais less than that of the drag springs 40 against the casing wall, thelower drag collar 10d will remain non-rotatable; so that rotation of thedrag sleeve 75b to the right will effect a downward feeding of the lowerdrag collar 7001 along the drag sleeve 151). This will pull the springs40 downwardly along the casing B until the upper drag collar 10a engagesthe stop sleeve 9|a. Continued rotation then feeds the lower drag collar10d further downwardly along the drag sleeves 15b to extend the dragsprings 40 lengthwise and pull them inwardly from engagement with thecasing wall (see Fig. 10).

The tubing string C may now be rotated, in order to disconnect thetubing sections above the rotary table without dragging the springs 40along the casing walls. Similarly, as in the other forms of theinvention, the slips l I cannot be set inadvertently during upwardmovement of the mandrel, even though the clutch ring 52 may be expandedfrom clutching engagement with the mandrel II], for the reason thatrelative upward movement of the mandrel ID with respect to the slips I!and the clutch and drag device 26 is pre vented. Such upward movement istransmitted through the stop ring 88a, stop sleeve 9Ia, upper dragcollar 70a, drag springs 19, lower drag collar 10d, drag sleeve 15b,ratchet sleeve 30, swivel 21 and linkage 20 to the slips H. The mandrelII] can move downwardly, but any further downward movement could, at themost, only retract the slips I! and the packing I6 to a further extentin the event they were not previously fully retracted.

It is also evident that during upward movement of the tubing string Cand mandrel II], the stop sleeve Sla engages the upper drag collar 10aand exerts a pulling action on the drag springs 40, moving such springsreadily past any resisting elements that might be encountered in thewell casing B.

The inventor claims:

1. In a Well tool for use in a well conduit: a first member adapted forconnection to a tubular string; a second member slidably andtelescopically arranged with respect to said first member; means fortransmittin the turning eiiort of said first member to said secondmember; conduit engageable means operatively connected with said secondmember for resisting movement of said second member in said wellconduit; and means, comprising a left-hand threaded connection betweensaid conduit engageable means and one of said members, for moving atleast part of said conduit engageable means longitudinally of saidmembers and the well conduit in response to rotation of said firstmember to a position enabling rotation of said first and second memberswithout dragging said conduit engageable means along the inner surfaceof the well conduit.

2. In a well tool for use in a well conduit: a first member adapted forconnection to a tubular string; a second member telescopically arrangedwith respect to said first member; means for transmitting the turningeffort of said first member to said second member; conduit engageablemeans cooperable with said second member for resisting movement of saidsecond member in said well conduit; means comprising a threadedconnection between said conduit engageable means and one of said membersfor moving at least part of said conduit engageable means longitudinallyof said members in response to rotation of said first member; andfriction brake means between said second member and conduit engageablemeans for resisting movement or" said second member relative to saidconduit engageable means.

3. In a well tool for use in a well conduit: a first member adapted forconnection to a tubular string; a second member slidably andtelescopically arranged with respect to said first member; means fortransmitting the turning effort of said first member to said secondmember; conduit engageable means cooperable with said second member forresisting movement of said second member in said well conduit; and meansproviding a connection between said conduit engageable means and saidsecond member which will efiect feeding of said conduit engageable meansdownwardly along said second member and the well conduit upon right-handrotation of said second member by said first member relative to saidconduit engageable means.

4. In a well tool for use in a well conduit: a first member adapted forconnection to a tubular string; a second member telescopically arrangedwith respect to said first member; means for transmitting the turningeffort of said first member to said second member; conduit engageablemeans cooperable with said second member for resisting movement of saidsecond member in said well conduit; means providing a connection betweensaid conduit engageable means and said second member which will eiiectfeeding of said conduit engageable means along said second member uponrotation of said second member; and friction brake means on said conduitengageable means contacting said second member.

5. In a well tool for use in a well conduit: an inner member adapted forconnection to a tubular running-in string; an outer member slidably andtelescopically arranged with respect to said inner member; means fortransmitting the turning effort of said inner member to said outermember; conduit engageable means cooperable 14 with said outer memberfor resisting movement of said outer member in said well conduit; andmeans providing a connection between said conduit engageable means andsaid outer member which will effect feeding of said conduit engageablemeans downwardly along said outer member and well conduit uponright-hand rotation of said outer member by said inner member relativeto said conduit engageable means.

6. In a well tool for use in a well conduit: a first member adapted forconnection to a tubular string; a second member slidably andtelescopically arranged with respect to said first member; means fortransmitting the turning effort of said first member to said secondmember; conduit engageable means cooperable with said second member forresisting movement of said second member in said well conduit; meansproviding a connection between said conduit engageable means and saidsecond member which will efiect feeding of said conduit engageable meansalong said second member and the well conduit upon rotation of saidsecond member by said first member relative to said conduit engageablemeans, and stop means on said first member engageable with said conduitengageable means.

7. In a well tool for use in a well conduit: a first member adapted forconnection to a tubular running-in string; a second member slidably andtelescopically arranged with respect to said first member; means fortransmitting the turning effort of said first member to said secondmember; longitudinally spaced collars disposed around said members;conduit engageable drag springs secured to said collars; and meansproviding a connection between one of said collars and said secondmember which will effect feeding of said one of said collars along saidsecond member upon rotation of said second member by said first memberrelative to said one of said collars.

8. In a Well tool for use in a well conduit: a first member adapted forconnection to a tubular running-in string; a second member slidably andtelescopically arranged with respect to said first member; means fortransmitting the turning effort of said first member to said secondmember; longitudinally spaced collars encompassing said members; both ofsaid collars being movable with respect to both of said members; conduitengageable drag springs secured to said collars; and means comprising athreaded connection between one of said collars and said second memberfor moving said one of said collars longitudinally of said second memberin response to rotation of said second member.

9. In a well tool for use in a Well conduit: a first member adapted forconnection to a tubular running-in string; a second membertelescopically arranged with respect to said first member; means fortransmitting the turning effort of said first member to said secondmember; longitudinally spaced collars disposed around said members;conduit engageable drag springs secured to said collars; meanscomprising a threaded connection between one of said collars and saidsecond member for moving said one collar longitudinally of said secondmember in response to rotation of said second member; and stop means onsaid first member engageable with the other of said collars.

10. In a well tool for use in a well conduit: a first member adapted forconnection to a tubular string; a second member slidably andtelescopically arranged with respect to said first member; means fortransmitting the turning effort of said first member to said secondmember; conduit engageable means connected to said sec ond member forresisting movement of said second member in said well conduit; and meansproviding a connection between said conduit engageable means and one ofsaid members which will effect feeding of said conduit engageable meansdownwardly along said members in response to right-hand rotation of saidfirst member and during rotation of said second member by said firstmember relative to said conduit engageable means.

11. In a well tool adapted to be lowered in a Well conduit on a tubularstring: normally retracted slip means; expander means for moving saidslip means into engagement with said well conduit; tubular meansoperatively connected to said expander means and connectible to saidtubular string; releasable lock means for selectively preventing orpermitting substantial relative longitudinal movement between said slipmeans and tubular means; a drag device operatively connected to saidslip means and frictionally engageable with said well conduit, said dragdevice including a first part rotatable and slidable on said tubularmeans and threadedly con nected to a second part, means for rotatingsaid second part by the tubular string relative to said first part inorder that rotation of said tubular string will feed one of said partslongitudinally with respect to the other of said parts and alsolongitudinally of said tubular means.

12. In a well tool adapted to be lowered in a well conduit on a tubularstring: normally retracted means; means for moving said normallyretracted means into engagement with the well conduit; tubular meansoperatively connected to said moving means; releasable lock means forselectively preventing or permitting substantial relative longitudinalmovement between said normally retracted means and tubular means; athreaded sleeve secured to said lock means; and friction means threadedon said sleeve and frictionally engageable with said conduit.

13. In a well tool adapted to be lowered in a well conduit on a tubularstring: normally retracted means; means for moving said normallyretracted means into engagement with the well conduit; tubular meansoperatively connected to said moving means; releasable lock means forselectively preventing or permitting substantial relative longitudinalmovement between said normally retracted means and tubular means; athreaded sleeve secured to said lock means; friction means threaded onsaid sleeve and frictionally engageable with said conduit; and slippablebrake means resisting relative rotation between said sleeve and frictionmeans.

14. In a well tool adapted to be lowered in a well conduit on a tubularstring: normally retracted means; means for moving said normallyretracted means into engagement with the well conduit; tubular meansoperatively connected to said moving means; releasable lock means forselectively preventing or permitting substantial relative longitudinalmovement between said normally retracted means and tubular means; athreaded sleeve secured to said lock means; friction means threaded onsaid sleeve and frictionally engageable with said conduit; and stopmeans on said tubular means engageable with said friction means.

15. In a well tool adapted to be lowered in a well conduit on a tubularstring: normally retracted means; means for moving said normallyretracted means into engagement with the well conduit; tubular meansoperatively connected to said moving means; releasable lock means forselectively preventing or permitting substantial relative longitudinalmovement between said normally retracted means and tubular means; asleeve secured to said lock means and having a threaded portion and anunthreaded portion; and friction means threaded on said threaded portionand frictionally engageable with said conduit, said friction means beingmovable along said threaded portion onto said unthreaded portion inresponse to rotation of said tubular means and sleeve.

16. In a well tool adapted to be lowered in a well conduit on a, tubularstring: normally retracted means; means for moving said normallyretracted means into engagement with the well conduit; tubular meansoperatively connected to said moving means; releasable lock means forselectively preventing or permitting substantial relative longitudinalmovement between said normally retracted means and tubular means; asleeve secured to said lock means and having a threaded portion and anunthreaded portion; friction means threaded on said threaded portion andfrictionally engageable with said conduit, said friction means beingmovable along said threaded portion onto said unthreaded portion inresponse to rotation of said tubular means and sleeve; ancl'stop meanson said tubular means engageable with said friction means upon itsmovement onto said unthreaded portion.

17. In a well tool adapted to be lowered in a well conduit on a tubularstring: normally retracted means; means for moving said normallyretracted means into engagement with the well conduit; tubular meansoperatively connected to said moving means; releasable lock means forselectively preventing or permitting substantial relative longitudinalmovement between said normally retracted means and tubular means; asleeve threadedly secured to said tubular means; and conduit engagingmeans connected to said lock means and slidably splined to said sleeve.

18. In a well tool adapted to be lowered in a well conduit on a tubularstring: normally retracted means; means for moving said normallyretracted means into engagement with the well conduit; tubular meansoperatively connected to said moving means; releasable lock means forselectively preventing or permitting substantial relative longitudinalmovement between said normally retracted means and tubular means; asleeve threadedly secured to said tubular means; conduit engaging meansconnected to said lock means and slidably splined to said sleeve; andstop means on said sleeve engageable with said conduit engaging means.

19. In a well tool adapted for use in a well conduit: a first member; asecond member movable relative to said first member; conduit engageablemeans cooperable with said second member to resist movement of saidsecond member within said well conduit; and means on said membersengageable with said conduit engageable means to retract saidconduitengageable means from said conduit.

20. In a well tool adapted for use in a well conduit: a first member; asecond member movable relative to said first member; a drag devicecomprising a first collar mounted on said first member, a second collarmounted on said second member, and springs connected to said collars andengageable with said conduit; and means on said members engageable withsaid collars and operable upon rotation of one of said members forincreasing the distance between said collars to retract said springsfrom said conduit.

21. In a well tool for use in a well conduit: a first member adapted forconnection to a tubular running-in string; a second membertelescopically arranged with respect to said first member; means fortransmitting the turning effort of said first member to said secondmember; longitudinally spaced collars disposed around said members;conduit engageable drag springs secured to said collars; meanscomprising a threaded connection between one of said collars and saidsecond member for moving said collar longitudinally of said secondmember in response to rotation of said second member; and slippablefriction means on said one collar engaging said second member.

7 22. In a well tool for use in a well conduit: a first member adaptedfor connection to a tubular running-in string; a second member slidablyand telescopically arranged with respect to said first member; means fortransmitting the turning effort of said first member to said secondmember; longitudinally spaced collars encompassing one of said members;both of said collars being movable with respect to both of said members;conduit engageable drag springs secured to said collars; and meanscomprising a threaded connection between one of said collars and one ofsaid members for moving said one collar longitudinally of said onemember in response to rotation of said one member.

REUBEN C. BAKER. PHILLIP B. ZIMMERMAN.

REFERENCES CITED The following references are of record in the file ofthis patent:

UNITED STATES PATENTS Number Name Date 2,300,438 Spang Nov. 3, 19422,368,400 Baker Jan. 30, 1945 2,368,401 Baker Jan. 30, 1945 2,368,737Badgley Feb. 6, 1945

